A Fundamental Model for Prediction of Hole Curvature and Build Rates With Steerable Bottomhole Assemblies

Abstract

ABSTRACT There are four key technical issues to be addressed when drilling directional wells with steerable bits and bottom hole assemblies: maximizing hole quality, addressing tool face control, eliminating bit and assembly vibration, and predicting hole curvature or build rates.Hole quality[1] and tool face control[2–7] have been covered in several previous SPE papers, as has bit and assembly vibration elimination[8–9].This paper covers the recent development of a fundamental model for the prediction of hole curvature based on measured bit response and modeled bottom hole assembly behavior. Bit side cutting is a nonlinear function of side force, gauge design, rotary speed, rate of penetration, rock strength, and cutter dull state. To characterize the bit's side cutting response, a series of tests are run in a full scale drilling simulator[10] under a variety of drilling parameters and sideloads.Axial and lateral bit trajectories are measured and a response curve is generated.The bit side cutting angle measured in the lab, is equivalent to bit tilt calculated on a bottom hole assembly (BHA). Several hundred tests have been run to measure the response of numerous bits.These response curves are then used to relate bit performance to BHA response. The BHA is modeled with a finite element analysis program over the range of hole curvatures and tool settings which define the operating envelope for the tool.The result of the analysis is a bit side force to bit tilt response surface for the tool over its operating range.The response curve for the bit and the response surface for the BHA are then plotted on the same set of axes. The intersection of the two graphs represents the steady state response of the system and is used to predict the achievable hole curvature of the bit-BHA system.This work shows that bits often selected for rotary steerable systems are more laterally aggressive than required of the BHA to achieve the desired hole curvature. The model has been verified with full scale field tests.While this work was originally developed for PDC bits and rotary steerable systems, the fundamental model can be applied to all types of bits and drilling systems. It has also been applied to motor and vertical drilling systems with PDC and Impregnated bits. BACKGROUND With the advent of directional drilling and increased horizontal reservoir targets world wide, it has become increasingly necessary to accurately place the wellbore within an ever shrinking target.With this in mind, there are four key technical issues to be addressed when drilling directional wells.Maximizing hole quality,Addressing tool face control,Eliminating bit and BHA vibrations, andAccurately predicting achievable bit-BHA build rate, or hole curvature. Recent studies on borehole quality have helped make in-roads to achieving high quality directional wells.A recent model was formulated by Pastusek and Brackin1 to study the origins and effects of borehole rippling, spiraling, and hour glassing. Significant progress has been made in understanding and improving tool face control with PDC drill bits.Specifically, the recent papers on reducing torque fluctuations with PDC bits have had a significant impact on utilization of these bits on rotary steerable systems.[2–7]